Hydrocarbon gas detection device

ABSTRACT

A device and associated method can detect hydrocarbon gas with at least a control module having a plurality of different gas detection means housed in a mobile enclosure, the control module configured to activate at least two different gas detection means to provide amounts and types of gases present in a fluid.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application claims benefit under 35 U.S.C. 119(e) of U.S.Provisional Application Ser. No. 61/733,250, which was filed Jan. 30,2013, which is hereby expressly incorporated herein by reference in itsentirety.

SUMMARY

Various embodiments may generally be directed to the detection ofmultiple different gases in a single sample.

Assorted embodiments configure a device with at least a control modulehaving a plurality of different gas detection means housed in a mobileenclosure and the control module configured to activate at least twodifferent gas detection means to provide amounts and types of gasespresent in a mixture of different gases.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 generally provides a block representation of an example gasdetection system in accordance with various embodiments.

FIG. 2 displays a block representation of an example gas detectionenvironment utilized in accordance with some embodiments.

FIG. 3 shows a block representation of an example gas detection devicecapable of being used in the example system of FIG. 1 and environment ofFIG. 2.

FIG. 4 is a block representation of an example gas detector capable ofbeing used in the example gas detection device of FIG. 3.

FIGS. 5A and 5B respectively illustrate top and exploded side views ofan example gas separator configured in accordance with variousembodiments.

FIG. 6 plots example operational data associated with a gas detectiondevice.

FIG. 7 displays a perspective side view of an example portable gasdetection device constructed in accordance with some embodiments.

FIG. 8 maps an example hydrocarbon detection routine carried out inaccordance with assorted embodiments.

DETAILED DESCRIPTION

The present disclosure generally relates to a device capable ofdetecting raw natural gasses using a multitude of sensor technologies inthe oil and gas field, more particularly in the detection of raw naturalgasses during the exploration of oil and gas in a drilling process.

As strata of rock formations are punctured through drilling andfracturing operations, natural gases may be freed and can indicate thecomposition of rock, volume of hydrocarbons, and effectiveness ofhydrocarbon extraction. Such freed natural gases are often pressed intoand trapped within drilling “mud” that is pumped at high pressurethrough the center of a drill string to cool and lubricate the drillingbit as it cuts through earth and rock. After passing through the drillbit, the mud can make its way back to the surface between the drill pipeand the hole outside the drill string while entrapping freed naturalgases due at least to the density of the mud compared to the gases. Thetrapping of natural gases may further occur while the mud is under largepressures and as such the mud will be infused with the various gassesassociated with the rocks and earth being fractured. That is, gassesemitted from oil and gas bearing rocks being drilled through are pressedinto the mud via large natural and artificial pressures associated withthe drilling operations and the depth of the drilling hole.

With the various natural gasses entrapped into the mud, the analysis ofthe mud can render the constituent gases and concentrations at variousdepths throughout the drilling hole. In some embodiments, the mudreaching the surface is immediately sent to a filter, such as a screenshaker, to remove the rock cuttings that can individually orcollectively be analyzed for solid, liquid, and gas composition toindicate the type and formation of rock being drilled, which may provideverification of geologist's report and hydrocarbon reservoirestimations.

However, accurately separating and measuring the various gassescontained in a mud sample has been challenging and costly due toenvironmental and equipment limitations can be exacerbated by theaddition of the constantly changing characteristics of the drilling mud.For example, drilling mud composites comprised of heavy hydrocarbonbased lubricants, such as diesel fuel or crude oil, can be difficult toseparate and measure with respect to the mud. In addition, the rawnatural gas may be released from the ground with around 90% to 95%methane composition with more complex gasses in concentrations of 5% orless with few exceptions.

While tools exist that are capable of measuring the composition of gasesthat may emanate from a drilling bore such as a chromatograph and massspectrometer, such equipment are not designed to operate concurrently ona single sample, survive harsh operating environments, be easilytransported, or provide precise measurements in field conditions foundon a drill site. For instance, a laboratory grade chromatograph, while ahighly accurate tool, has not been adapted to the problematic electricalsystems often found in drilling environments or reduced in size to allowphysically robust casings, which will quickly degrade a typicallaboratory grade chromatograph system into uselessness at a well site.

Further issues can plague field use of laboratory grade chromatographsystems as daily and sometimes hourly recalibrations are necessary toprovide reliable measurements. The use of a chromatograph may includecolumn chemicals that are hygroscopic, which poses a number of accuracydifficulties in oil field use as water is absorbed into the columnchemicals making them useless over time for measuring well samples thatoften have both high levels of water vapor and oxygen. Laboratory gradechromatographs may also require a specific column temperature to bemaintained within a very tight temperature range to garner repeatabilityand accuracy.

Even with the various issues in measuring a gas sample using achromatograph, the precision of the instrument often is not reliableenough to discern different hydrocarbons, such as between Methane (C1)and Ethane (C2), as the Methane to Ethane ratio may be too large, suchas a 90 to 1 ratio, and the gasses are so close in molecular weight thatmost if not all chromatographs have trouble returning to a baselineseparation of these two gasses. Some chromatographs require large andheavy tanks of travel gas such as Hydrogen or Helium and in the case offlame ionization detector (FID), or other flame photometers, a specialheavy and bulky FID fuel gas tank is required, which impedes the abilityto transport, set-up, and administer a series of reliable tests as theinstrument becomes useless if any of these tank gasses run empty.

With these issues in mind, various embodiments may generally be directedto a gas detecting device capable of utilizing multiple sensors andsensor technologies according to various predetermined logicalalgorithms to detect the types and amounts of gases present in a singlesample. For instance, a gas detecting device may have at least a controlmodule having a plurality of different gas detection means housed in amobile enclosure with the control module configured to activate at leasttwo different gas detection means to provide amounts and types of gasespresent in a mixture of different gasses. The ability to monitor,modify, and control a variety of different gas detecting means accordingto a logical algorithm can allow for efficient adaptation of the gasmeasuring process to account for diverse and variable conditions, suchas ambient temperature, barometric pressure, and humidity. Theautomation and varying control of multiple gas detectors may furtherallow for a concise physical device constructed that is robust tovibration, weather, electrical supply, transportation, abnormalities,and calibration.

FIG. 1 generally provides a block representation of an example gasdetection system 100 configured in accordance with various embodimentsto detect the types and amounts of gases in a single sample. The system100 has a hydrocarbon gas detection device 102 connected to a wellbore104 and a network 106. Such position of the gas detection device 102allows various aspects of the device 102 to engage assorted portions ofthe wellbore 104 while connecting to and communicating with any numberof remote nodes to download and upload data, compute gas detectionalgorithms, and operate in conjunction with other devices.

In the non-limiting example of FIG. 1, the hydrocarbon gas detectiondevice 102 is constructed with at least a sensor 108 and detector 110that can be utilized concurrently and independently to identifyenvironmental and testing fluids that have entrapped gasses from thewellbore 104 recently after fluid has been evacuated from the wellbore104, such as less than five minutes after evacuation. The gas detectiondevice 102 may further have one or more interfaces 112 that communicatewith a user and peripheral devices while enabling a network protocol 114to establish, maintain, and service the transfer of data across thenetwork 106. These gas detection device 102 components are not requiredor limiting, but can allow for data to be remotely computed via at leastone processor 116, stored in a remote memory 118, and combined with datafrom other devices 120, such as other environmental, mechanical, andhydrocarbon detection equipment.

It can be appreciated from FIG. 1 that the hydrocarbon gas detectiondevice 102 can be utilized in a variety of different manners andenvironments where hydrocarbons are present. FIG. 2 displays a blockrepresentation of a portion of an example hydrocarbon environment 130 inwhich a hydrocarbon gas detection device can be employed in accordancewith some embodiments. As shown, at least one hydrocarbon gas detectiondevice 132 can be positioned outside a wellbore 134, which isconstructed with a wellbore sidewall 136 and drilling piping 138, suchas casing and rotating drilling pipe, positioned therein.

It is to be understood that the wellbore 134 can be any depth 140 andhave constant or varying amounts of drilling fluid 142, such as drillingmud, stagnant or flowing below the ground surface 144. The gas detectiondevice 132 can be configured to engage and measure the amount of gaspresent in any location within the wellbore 134, such as outside andinside the drilling piping 138. Such engagement is not restricted to aparticular type or size of probe, sensor, or receptacle and can measuredrilling fluid that has gas, liquid, and solids individually andtogether by contacting a sample. In assorted embodiments, the gasdetection device 132 removes a drilling fluid sample from the wellbore134 or from a fluid retaining structure 146, such as a mud pit, andanalyzes the sample in a controlled environment. However, otherembodiments conduct some or all of the drilling fluid analysis while thefluid is resident in its native location, such as the wellbore 134 andretaining structure 146.

With the ability to engage drilling fluid 142 at different locations inand around a wellbore 134, the gas detection device 132 can measure thedrilling fluid 142 under diverse conditions that allows for increasedgas detection accuracy. For example, drilling fluid 142 readings can becompared between downhole measurements and controlled environmentmeasurements to ensure gas types and amounts were not lost duringtransport. It should be noted that the controlled environment in whichdrilling fluid 142 is measured external to the wellbore 134 andretaining structure 146 can be any size and duration with one or moreconditions being controlled, such as pressure, temperature, light,humidity, and fluid density.

While a gas detection device may be configured with any number ofcomponents to be used in a wide variety of environments, FIG. 3 providesa block representation of an example gas detection device 150 that canefficiently and reliably measure a single sample and detect the typesand volumes of constituent gases. The gas detection device 150 has aprocessor 152 that can be a part of a computing system that stores datain memory, runs software, and communicates over a network viaappropriate protocol. The processor 152 can be configured to control atleast a gas separator 154, electronic display 156, various sensors 158,and one or more gas detector means to take a gas sample and conducttesting in accordance with a locally or remotely stored logicalalgorithm to discern the various gases that make-up the sample.

Among the unlimited variety of detection equipment capable of beingcontrolled by the processor 152, a hot-wire based detector 160, photoionization detector 162, thermal coefficient detector 164, pellistorbased detector 166, infrared detector 168, oxygen detector 170, andhydrogen sulfide detector 172 may be used individually, sequentially, orconcurrently to analyze a sample. With past incarnations of the hot-wire160 and pellistor 166 based detectors, the detector would becomecarbonized or burn out with too much methane or raw natural gas beingpresent in the detector chamber. The previous use of an infrareddetector 168 for hydrocarbon measurement was attempted but discontinueddue to the fact that infrared detection varied wildly with temperatureand the different gasses found in the drilling fluid.

Even with gas detection instruments like the Bloodhound System made byiBall Instruments of Edmond, Okla., infrared detectors can beinefficient, on its own, as the detection systems have to adaptivelylearn the reactivity of the gasses and adjust the infrared detectors onthe fly. With the gas detection device 150 shown in FIG. 3, theprocessor 152 can utilize any of the various detectors in accordancewith the predetermined logical algorithm in order to provide the mostaccurate and efficient gas measurement. In some embodiments, theprocessor 152 can choose or adapt the logical algorithm in response toreadings from one or more sensors 158, which allows the algorithm toactivate the best possible detector to provide the most accuratemeasurement given the sensed conditions.

The gas detection device 150 is not limited to the configuration,connections, and equipment provided in FIG. 3, as any number of similarand dissimilar detectors and detection technologies can be cooperativelyutilized individually, sequentially, and concurrently to providemonitored and automated testing of a sample to better gauge the absolutevalue of the raw natural gasses in the sample. The ability to utilizemore than one detector of a single type provides redundancy to thedevice 150 that can be utilized for optimized accuracy and devicereliability in the field. Additionally, the multitude of different gasdetecting technologies combined with the ability to switch betweentotally separate types of gas detectors allows the device 150 to adaptto changing conditions, such as measure environmental conditions fromthe sensor 158 and damage to a plurality of detectors. In the eventdamage is detected, the device 150 can logically disconnect the failedor damaged sensors and continue operating one or more other detectors,in some embodiments.

As an example of the characteristics of gas detectors that can beselected by the processor 152, the hot-wire based detector 160 can beactivated to efficiently detect low levels of natural gas, but would bedamaged when higher levels of gas are detected. Hence, the processor 152can deactivate the hot-wire based detector 160 at a predeterminedthreshold, such as an elevated temperature or pressure, and startutilizing another detector like the infrared detector 168 or the thermalcoefficient detector 164 for high level detections. The gas detectiondevice 150 may further be responsive to extremely low natural gaslevels, in which the photo ionization sensor 162 could be initiallyutilized instead of the hot-wire based detector 160.

In some embodiments, more than one detector of each type are includedinto the device 150 to provide alternatives for the processor 152 suchas when a detector is being calibrated or cleaned. Also, theminiaturization of electronics can allow for such redundant detectorswithout increasing the physical size of the device 150 to the pointwhere it is not portable. Such reduced physical size of computingcomponents is complemented by the increased computing power of suchcomponents to allow seamless, automatic, and unnoticed device 150testing.

FIG. 4 generally illustrates a block representation of an example massspectrometer 180 that may be used in the gas detection system 100 ofFIG. 1, in the gas detection environment 130 of FIG. 2, and with the gasdetection device 150 of FIG. 3 in accordance with assorted embodiments.The mass spectrometer 180 can, in various embodiments, be used at an oilwell site, but may have significant operational and structuraldisadvantages in their present construction. Compared to a chromatographthat uses a chemical column based means of gas separation, the massspectrometer 180 uses the principal of ionizing the sample gas andinjecting it into a high vacuum field across a very high magnetic field.The charged particles are then deflected by the field to a differentvector of travel and thereby striking isolated plates causing theelectrically charged particle to transfer the charge to the isolatedplates. In theory, the charged plate is then amplified to give arespective output of the gas stream of charged particles, which shouldgive results almost instantly of all gasses that are monitored.

In practice, a mass spectrometer 180 is not practical field equipmentdue at least to gain block, large vacuum chamber needed to test,operational temperature, and multiple sources of contamination. With afirst gain block that may be over a billion, the tiniest change intemperature or electrical deviation can cause large unpredictableresults. For instance, a chamber vacuum that is almost an absolutevacuum can contaminate the chamber with normal air particles that becomecharged and degrade the accuracy and sensitivity of all the readings.Contamination of the vacuum chamber and electrical aspects, such as a PCboard, of the mass spectrometer 180 with any debris or materials willcause deviations as the material on the high-gain feedback resistorscause large drifts.

The use of a mass spectrometer 180 is not required or limiting, but canbe used in various embodiments to provide gas measurements, such as inlow environmental contamination sites or with other chemical gasseparations. Since the natural gasses being tested are themselvesreactive to chemical compounds, there are ways to chemically isolate thegasses such as taking rock samples, or cuttings, to a laboratory to becrushed and analyzed. Analyzing gasses contained in rock cuttings caninvolve placing them into a vacuum chamber where the gasses can bepulled out under high vacuum and heat and then pulled through alaboratory grade chromatograph. The removal of rock cuttings fromdrilling mud can allow for the chromatograph to be used in a laboratoryenvironment, which increases reliability and accuracy of the results, ifconducted properly.

However, the excavation of rock cuttings can lack the breadth and timingof an on-site gas analysis from drilling mud as gases escape from therock during transportation to the laboratory. While air tight containersmay be used to reduce gas leakage, accurate testing of escaped gasesafter the delay of transportation is not as accurate as on-site testing.Hence, an on-site testing of drilling mud for natural gases entrappedtherein can provide a more precise and accurate real-time perception ofthe type and yield of the hydrocarbon reservoir being drilled.

The utilization of one or more gas detectors, such as the infrareddetector 168 of FIG. 3 and the mass spectrometer 180 of FIG. 4, with alogical algorithm and the ability to adapt to sensed conditions bothenvironmentally and with the sample can provide more accurate on-sitegas measurements, but the separation of gas from the drilling mud thatoften contains a variety of heavy, light, and aromatic materials likediesel fuel can be difficult without losing a portion of the entrappedraw natural gases. It has long been known that if an object is immersedin a liquid, that object will displace a volume of liquid equivalent toits own volume. By comparing the weight of the object and the weight ofthis displaced volume of liquid, you can determine if the object willfloat or sink.

When a balloon is filled with something other than air and then releasedinto air, it will float or sink based on the same principle. If theweight of the volume of air displaced by the balloon is less than theweight of the balloon and the gas inside, the balloon will drop to theground. If the weight of the air displaced by the balloon is greaterthan the weight of the balloon and the gas inside, the balloon willfloat upwards. This force, or buoyancy, either positive or negative, isexactly the difference in the weight of the balloon and its contents,versus the weight of the volume of air displaced. This is the principalbehind the Specific Gravity of a material.

In principal, the gasses we breathe are made up of nitrogen (N²), oxygen(O²), and many other gasses that do not bond together but are constantlybeing mixed up in our atmosphere with very similar molecular weights.Breathable air constituent gases do not generally separate but are happyjust sitting together in a constant atmospheric soup. In contrast,natural gas comes from the ground and is primarily Methane and lowerconcentrations of other gasses, as provided in Table 1.

TABLE 1 General Raw Natural Gas Concentration Methane (CH4) 70%-90%Ethane (C2H6)  5%-15% Propane (C3H8) <5% Normal butane (n-C4H10) BalanceIsobutane (i-C4H10) Balance Pentanes C5H12 Balance CO2 Balance H2SBalance

With raw natural gas containing known gases that have a specific gravitythat can be physically separated via mechanical separation, such as witha centrifuge, may be used in some embodiments to aid in the time,sensitivity, and accuracy of gas detection with the device 150 of FIG.3.

As shown in FIGS. 5A and 5B, a gas centrifuge 190 can be adapted tofacilitate hydrocarbon separation and testing that provides accurateresults in less than two (2) minutes and in some situations less thanthirty (30) seconds. Extracted gasses from the mechanical extractorlocated at a shaker, such as a possum belly or spoil separator, cancontain a plethora of diverse materials from pure air to almost purediesel to crude oil fumes. The raw natural gas that needs to beseparated and quantified is trapped within as only a small part of theoverall extracted gas as the diesel and other heavy hydrocarbon fumescan overpower and overtake most current hot wire or pellistor baseddetector systems forcing most systems that use petroleum based drillingmud to heavily dilute the incoming sample with air, which is known asair dilution. In doing so, the sample to be analyzed has also beendiluted at a predetermined ratio like 10:1 or more. Such air dilutionreduces the effectiveness of a gas centrifuge as constituent gasportions are reduced and makes accurate gas measurements difficult.

The use of infrared gas detectors may be used in various embodimentswith the gas centrifuge 190 to measure high background gasses withoutoverwhelming the equipment with undiluted air. As shown in Table 2, thegasses expected from raw natural gasses have specific gravity levelsfrom 0.55 to 2.9 while other heavy hydrocarbons have been omitted thatwould be typical in the hydrocarbon based drilling mud.

TABLE 2 General Natural Gas Specific Gravity Air reference 1.0000 (20.9%O2, 78% N2) Hydrogen 0.0696 Helium 0.1380 Methane 0.5537 Nitrogen 0.9669Ethane 1.0378 Oxygen 1.1044 Carbon Dioxide 1.5189 Propane 1.5219n-butane 1.9400 iso-butane 1.9400 Pentane 2.4870 Hexane 2.9730 Heptanes3.4590 Octane 3.9440Each of these gases have a specific gravity level that is much greaterthan air, which allow a centrifugal separation to be effective.

While not required or limiting separation of gases with a centrifugewould start in various embodiments with a chamber flush that consists ofpushing air into and out of the chamber 192 to flush any hydrocarbonsthat are remaining in the chamber 192. Next, the sample gasses would bepushed into the chamber 192 where they would be turned at apredetermined speed inside the centrifuge 190, such as 8000, 12000, and15000 RPM. Inside the centrifuge 190 the gasses are separated into bandsof gas according to their respective specific gravities. The centrifuge190 would be capable of separating gasses with differences in specificgravity greater than 0.2 units, as provided in Table 2.

The gasses are subsequently drawn slowly out of the chamber 192 andacross a sensitive detector where each band is detected and quantified.It is of note that since the output is from a centrifuge, instead of achromatograph, both time and amplitude can be used to quantify the gasmeasurements. The wider the band based on time, the amount of gas persample, and the amplitude of the gas can dictate which band it has comefrom to aid the sensitive detector in identifying gases due to thesensitive detector having predictable output reaction to different typesof gas.

In some embodiments of device 150 of FIG. 3, the centrifuge isconfigured with a chamber 192 measuring approximately 4″ diameter thatwill have to turn at around 8000 RPM. Based on the general principal ofrotational G force calculations of:

G (RCF)=0.00001118×Radius in cm×RPM²  Equation 1

With a rotational speed of 8000 RPM, the G force for a 2 inch chamber152 is 18,174 G and 36,348 G for a 4 inch chamber 192. Such force shouldprovide acceptable separations within a few seconds.

The use of such force may be effective and efficient, but can be easilyundone if the separated gases remix as they are drawn from the chamber192. Any internal turbulence may cause the stacked and now separated gascolumn to collapse and the gases to once again intermingle. Accordingly,a predetermined artificial gravity can be induced by maintaining thecentrifuge 190 at a reduced, above zero, speed, such as 500 RPM, toprevent gas remixing while gases are drawn from the chamber 192 andmeasured.

Along with gas remixing, turbulence may occur within the chamber 192 andthe lines transporting the gases to a detector. Excessive turbulencecould cause the gasses to intermingle and ruin the separation anddetection process. To keep turbulence to a minimum, a septum disk 194should be chamfered at the edge and the transition points smoothed toensure laminar flow of gases during extraction. Such laminar flow mayfurther be controlled by gradually starting the vacuum extractionsystem, which can easily be done with accurate and precise control ofthe draw vacuum that has the separated gasses pulled from the center ofthe centrifuge 190.

FIG. 5A illustrates a top view of a portion of the gas centrifuge 190with a plurality of chambers 192 radially extending from an inletaperture 196. As shown in the exploded side view of FIG. 5B, the gascentrifuge 190 can be constructed of two joining disks respectivelyconfigured with chambers 192 and outlet veins on opposite sides of theseptum disk 194. The outlet veins can be constructed with apredetermined diameter and positioned at predetermined locations toallow a particular volume of gas to be extracted either while spinningor during controlled vacuum pressure.

The separate centrifuge components may be sealed by a sealing feature,such as an O-ring resting in a groove 198 continually extending aroundthe various chambers 192. A ridge 200 may further be included in eachchamber 192 to align the septum disk 194 and maintain position duringoperation. With the non-limiting embodiment shown in FIGS. 5A and 5B,the centrifuge 190 is designed as a horizontal fixture that holdstapered sealed Timken bearings and weighs less than ten (10) pounds,which facilitates mobility for drilling site use.

Through the various embodiments of the present disclosure, hardware hasbeen generally illustrated that is capable of rendering separate gasesand testing those gases for volume. While the hardware can provideefficient separation, control of the various gas detectors, separatorspeed, and adapting to environmental and operational conditions can makethe difference between accurate and unreliable test results. FIG. 6graphs an expected output waveform 210 resulting from operation of a gasdetection device, such as device 150 of FIG. 3, according to apredetermined logical algorithm (PLA).

The PLA is the logics in which the intelligence and automation of a gasseparation device combines to control sensors within the device itselfand make changes to its logistical algorithm on the fly. That is, themultitude of the same type of sensor as well as a multitude of differenttypes of sensors can be logically controlled by the PLA to ascertain theamounts of the varied and different types of gasses within the collectedsample itself while also having the ability to self-correct for errors.

As a non-limiting example of the PLA, a gas detection device is assumedto have an infrared detector known to be more accurate at greater than5% methane, a pellistor based detector known to be more accurate at lessthan 5% methane, an oxygen detector that does not detect or react tomethane or its variants. Such an example gas detection device cansimultaneously compare readings from all three detectors and making thefollowing logical considerations:

-   (1) if the Oxygen sensor is at 20.9% (100% room air) then    -   (a) the infrared sensor should show 0% methane    -   (b) the pellistor sensor should show 0% methane-   (2) if the Oxygen sensor is at 19.5% then    -   (a) the infrared sensor should show 5% methane    -   (b) the pellistor sensor should show 5% methane-   (3) if the Oxygen sensor is at 10.45% then    -   (a) the infrared sensor should show 50% methane    -   (b) the pellistor sensor should be shut off to prevent damage-   (4) if the Oxygen sensor is at 0.1% then    -   (a) the infrared sensor should show almost 100% methane    -   (b) the pellistor sensor should be shut off to prevent damage

The logics stand to reason that the PLA should also consider the inversefindings as well in the same preceding scenario:

-   (1) if the infrared sensor is at 0% methane then    -   (a) the Oxygen sensor should show 20.9% (room air)    -   (b) the pellistor sensor should show 0% methane-   (2) if the infrared sensor is at 5% methane then    -   (a) the Oxygen sensor should show 19.5%    -   (b) the pellistor sensor should show 5% methane-   (3) if the infrared sensor is at 50% methane then    -   (a) the Oxygen sensor should show 10.45%    -   (b) the pellistor sensor should be shut off to prevent damage-   (4) if the infrared sensor is at almost 100% methane then    -   (a) the Oxygen sensor should show about 0.1%    -   (b) the pellistor sensor should be shut off to prevent damage

Further the PLA has an ability to self-calibrate and correct itself inthe following scenario:

-   (1) The Thermal Coefficient Detector (TCD) is showing 50% methane-   (2) The infrared detector is showing 50% methane-   (3) The Oxygen sensor is showing 8% Oxygen (should be 10.45%)

Based on the basic principal that the majority of gas detectingtechnologies will be accurate, the unexplained and unexpected Oxygensensor technology value will be judged to be inaccurate and thus the PLAwill correct this Oxygen calibration point to 50% or (10.4%) in thepreceding scenario thereby correcting a calibration point andself-calibrating the Oxygen sensor.

Further the PLA has the ability to detect failed sensors and correctitself in the following scenario:

-   (1) The Oxygen sensor is showing 10.45% Oxygen (50% room air)-   (2) The infrared detector is showing 50% methane-   (3) The Thermal Coefficient Detector (TCD) is showing 0% methane;

Based on the basic principal that the majority of sensor technologieswill be accurate, the unexplained and unexpected sensor technology valuewill be judged to have failed due to the great inaccuracy of the TCDoutput compared to other sensor technologies and thus the PLA willdisallow and ignore further reading from this one TCD sensor untilcorrected and may opt to start watching a back-up TCD sensor.

Overall, with the collection of different gas detectors available to thePLA, the gas detection device can clearly pick and choose between aplurality of technologies, compare all detectors available to it andcome to a more accurate output as well as correct for drifting sensorsor ignore failed sensors all together in favor of backup sensors, orother good detectors with more expected outputs.

Further, the PLA, upon its final calculations may also opt to averageall, some or one of the detector's measurements and then output thecalculated real natural gas outputs. The PLA also has the option tomonitor the temperature of the various detectors, and the humidity ofthe sample gasses which can have a large effect upon the reactivity ofthe gasses upon the sensors. When taking into effect the temperature andhumidity of the sample gasses, the PLA can also opt to correct thecalculations from each sensor and automatically compensate for any knowndrifting due to such temperature and/or humidity changes in the sample.

One issue in the examination of drilling mud can be that some drillingfluids are based primarily on diesel fuel, raw crude oil, or othervolatile chemicals instead of water. In such a case, some detectionequipment technologies can react to the fumes created by these organicdrilling fluids and indicate methane where there is little or no methaneat all. In this case the PLA can re-calibrate for the volatile organicdrilling fluid fumes since some of the detectors within the device donot react to these organic fumes, such as the Oxygen and HydrogenSulfide detectors. More to the point, if the operator notifies the PLAthat the drilling fluid is not water based, then the PLA can proactivelyre-calibrate to compensate for the known fumes.

The PLA, when notified by the user that the drilling fluid is not waterbased, can also opt to change the voltages upon the pellistor andhot-wire or pellistor based detectors. It is not commonly known that onecan reduce the voltage on these types of sensors and such heavyhydrocarbon fumes will cease to react to the catalyst that these sensorsare built upon. Thus, the PLA can correct for organic fumes in this wayas well. The PLA can also control the temperature of an individual orcollective set of detectors. It is not well known that different sensorsreact differently at different static temperatures. To reduce theinaccuracy of the collection of sensors, the PLA can monitor andmaintain all or some sensors to a known temperature thereby eliminatinga major source of sensor errors.

While the PLA can be implemented in a variety of gas detection devices,FIG. 7 displays an example portion of an example gas detection device220 configured in accordance with various embodiments. The placement ofvarious gas, electrical, and computer connectors on a portable gasdetection device can be problematic in that the connectors are harder toget to in order to service the portable gas detection device and saidconnectors. As shown by the gas detection device 220 of FIG. 7,placement of all gas inlets and outlets on the external left sidesurface of the device case 222 can provide efficient access, service,and function catered to drilling field site operations and specificsystem function, like the Bloodhound™ system by iBall Instruments.

While the specific location, connection, type of connection, andfunction of the various inlets and outlets of the gas detection device220 are not limited to the configuration shown in FIG. 7, variousembodiments position include at least a sample line inlet port 224, casevent 226, GPRS (or) CDPD external radio antenna connection 228, Sonalertaudible alarm device 230, sample line exhaust port 232, electricalbreaker for DC input/output port 234, direct current input/output port236, main AC power input port 238, geolograph switch input 240, pumpstroke switch(s) input 242, Pason Military style RS422 external WITSinterface 244, and DB9 external WITS interface 246 connections.

More specifically, various embodiments may configure the sample gasinlet 224 with a smaller ¼″ hose barb connection on the side is for thesample gas in. Right before this connector, there can be a line filterand a water catch canister (dropout jar). The filter is to removeparticulate materials and contaminates that may clog up the sample lineinlet port and damage the instrument. All the sample line connectionsshould be attached firmly using some type of hose clamp. The catchcanister should be rated for a minimum of 150 PSI. These ratings maycorrespond because the Bloodhound™ system will automatically attempt toclear a blocked sample line with sudden positive pressures between 50PSI and 110 PSI when in a sneeze or blowback mode of operation.

The case vents 226 are two small ports that allow the device 220 toregulate and monitor atmospheric pressures and also allow device 220 tomaintain internal pressure equilibrium. Meanwhile, the GPRS or CDPDCellular Network Radio Connection 228 can be a SMA antenna connectionfor the wireless GPRS or CDPD internet connectivity. Normally, a 5 dBgain magnetic mount antenna is connected here. This radio connectionallows the device 220 to connect to other devices, such as devices 120of FIG. 1 for reception of data. This is only one communications linkthat allow device 220 connection to the network to allow remotetechnicians to control, diagnose, adjust, reprogram, or maintain thedevice 220.

Below the radio connection, an audible alarm module 230 is positioned.This alarm will sound when the device 220 detects a problem with thesystem or one of the parameters it is monitoring goes into alarm state.The sample gas exhaust port 232 is a ½″ hose barb connection. Thislarger size exhaust hose keeps the system from developing a backpressure or getting plugged with ice during cold weather. It may bedisadvantageous to plug the exhaust line or use a smaller ¼″ hosebecause exhaust line back pressure may increase and the system may notoperate correctly.

With the electrical components of the gas detection device 220, theelectrical breaker 234 can provide protection as it will be tripped ifthe incoming or outgoing amperage is over a predetermined threshold,such as 8 amps or above. When the breaker 234 is tripped, the whiteround poppet will not be flush with the housing. To reset the breakerjust push the white round poppet back into the housing until it isflush. The device 220 DC power port 236 allows the user to either powerthe device 220 from an external 12VDC source such as a vehicle, or topower an external DC Cavitator extractor system from the internal powersupply. The DC port has overload, spike, sag and transient protectionbuilt in. If powering the device 220 from a DC power port from anautomobile, the power port 236 can be configured to indicate anincorrect polarity being used, which can cause a fuse in the automotivesystem to open. As an added feature, and with the correct adapter, this12 volt DC power port can operate a variety of different automotiveappliances, such as a cell phone charger, GPS, and a mobile computer.Various embodiments limit the output current from the power port 236 to8 amperes by a breaker.

Below the DC port is the universal AC power input 238. This AC input canhandle from 90-260 volts AC and from 43-68 hertz (Hz) (or) up to 300VDCbut may be modified without limitation to allow overseas operation on240 volts, 50 Hz as well as 120 volts, 60 Hz operation. The upper redand black spring terminal clamps are for the geolograph switch input240. In drilling environments that are not WITS or WITSML compliant, themost common method to transmit drilling foot changes, other than WITS,is with a switch connected in some manner to a mechanical geolograph. Asmore drilling rigs become WITS and WITSML compliant, this should be lesscommon. The lower red and black spring terminal clamps are for the pumpstroke(s) switch input 242. Connecting a switch or inductive sensor tothe armature of the drilling pump and then running the switch lines tothis input will automatically allow the device 220 to monitor switchinduced pump strokes. If there is more than one drilling pump, multiplepumps can be monitored by running the switches in parallel.

In order to communicate to the Pason Electronic Drilling Recorder (EDR)system without the burden of any external hardware, the gas detectiondevice 220 can be configured with a Pason compatible RS422 connectioninterface 244 into the device 220. This allows for direct connection tothe Pason EDR system to obtain duplex WITS communication andinformation. Generally, no user intervention is necessary on the device220 to access the Pason WITS information when using this connection.After connecting the 10 pin round military type cabling to the device220 from the Pason EDR system, the device 220 can automaticallyestablish communications with the Pason system and start acquiring andsending WITS data.

If the drilling rig has a TOTCO, EPOCH or other drilling system, thenthe communications from the drilling computer to the device 220 may comefrom a different source. If connecting the device 220 to a TOTCO system,a TOTCO technician might have to come to the drilling site and hook up asecondary computer. This computer talks to the rig and makes availablethe WITS information through a 9 pin null modem cable to the device's 9pin WITS port 246. If connecting to an EPOCH system, the WITS data comesfrom a box called a Device Extender, which allows for depth pulses, pumppulses, and on bottom marking. In accordance with assorted embodiments,the device 220 has one or more serial ports for WITS data. Connectingthe device's 9 pin male WITS connector through a null modem cable to theEPOCH system, COM 1, allows serial data transfer to and from the device220.

Along with the gas inlet/outlet and testing controls provided on thelower half of the device case 222, a plurality of computer inputs 248may be positioned on an opposite top half of the device case 222. Theplurality of computer inputs 248 may have at least RJ45 connector tohook into a local Ethernet network and operates using DHCP (Dynamic HostConfiguration Protocol) services. This Ethernet connection can be tiedinto the Internet as well as to other devices. If so, the device 220 canutilize such a connection to communicate with a remote server, such asan iBall Instruments server system. The plurality of computer inputs 248may further have 4 user accessible USB connections that are rated forUSB 2.0 speeds or greater. A large number of external devices can beconnected into the device 220 for ease of use by the system user. If thedevice 220 is to be used locally, the user will need to supply a monitorof their choice. The monitor will need to connect to the VGA connector,which is efficiently incorporated into the plurality of computer inputs248.

It can be appreciated that the consolidation of electronics into themobile device case 222, which may weigh less than 100 pounds in assortedembodiments, can allow for the testing of fluids and communication oftesting results in a variety of different manners. For instance, fluidmeasurements taken by one or more gas detectors can be logged andcomputed by a computer connected to the gas detection device viacomputer inputs 248 before gas types and amounts are communicated to aremote destination via the radio antenna 228. Other embodiments utilizethe various peripheral inputs, like interface 244 and WITS port 246, tofacilitate fluid testing and communicate fluid test results.

FIG. 8 maps an example hydrocarbon detection routine 260 carried out inaccordance with various embodiments without being limiting in any way.Initially, routine 260 can begin with step 262 receiving the basis ofthe gasses from the fluid being measured, such as water based or oilbased fluid. The basis of the fluid to be tested allows the logicalalgorithm to monitor, calibrate, and adjust the various gas detectorsand controlled testing environment to maximize the efficiency andaccuracy of gas detection. The calibration of various testing conditionscan occur before or during step 264 where fluid is concurrently testedwith at least two different gas detection means, such as infrared andthermal coefficient detectors.

Assorted embodiments utilize a multitude of different gas detectionmeans sequentially, individually, and simultaneously per the logicalalgorithm's direction. That is, the logical algorithm can trigger theactivation and deactivation of one or more different gas detection meansto maximize testing efficiency and accuracy. As a non-limiting example,a predetermined accuracy threshold, like 95% certainty, can beestablished prior to or during the testing of a fluid to ensure gasdetection results render accuracy above that established threshold. Step266 compares the logged measurements from the various gas detectionmeans in step 264 to determine a testing accuracy, which can be a rangeof numbers as well as a specific value.

With the accuracy of the fluid testing determined, decision 268 thenevaluates if a predetermined threshold accuracy has been met by thetesting conditions of step 264. In the event the threshold accuracy hasnot been met, an unlimited variety of steps and operations can beundertaken by the gas detection device to provide gas types and amountscontained in the tested fluid with accuracy above the predeterminedaccuracy threshold. For instance, at least one reading from a gasdetection means can be ignored in step 270, which allows results from amalfunctioning or inappropriate gas detection means to not taint resultsfrom other gas detection means. Step 270 can be followed by arecalculation of gases constituent in the tested fluid and a comparisonof the accuracy of the newly calculated results to the predeterminedaccuracy threshold back at decision 268.

Either initially or after another operation has failed to meet thethreshold accuracy, step 272 can self-calibrate one or more gasdetectors. Such self-calibration may take the gas detection meansoffline or remain online while environmental conditions, such astemperature, humidity, and pressure, are used to compute new gasdetection thresholds, which can be conducted passively and without userinitiation to provide seamless gas detection. Subsequently, theself-calibrated gas detector can test or retest the fluid to providemore accurate gas detection. However, the return of step 272 to decision268 indicates that the accuracy of the newly calibrated gas detector ischecked against the predetermined threshold accuracy instead of assumingthe self-calibration renders a more accuracy gas reading.

Upon failing decision 268, step 274 can alternatively use one or moredifferent gas detectors to increase gas detection accuracy. Step 274can, in some embodiments, redundantly check for the presence and volumeof gases under different conditions like varying pressures and after thegas centrifuge has separated gases. The ability to utilize multipledifferent corrective steps to increase the accuracy of gas detectionallows routine 260 to adapt to changing environmental and fluidconditions to ensure outputted gas results have not been jeopardized byerrant, miscalibrated, or inappropriate test detectors.

Regardless of what corrective steps are used to increase the accuracy ofgas detection, or in the event no corrective steps are conducted, a gasdetection accuracy above the predetermined threshold accuracy advancesroutine 260 to step 276 where the constituent gas types and amounts forthe tested fluid are outputted in real-time. A non-limiting example ofsuch real-time output may be in the form of a running log that isperiodically examined, a network stream that is continuously monitoredfrom a remote location, and a datum point that is evaluated by softwareto provide diagnostic and projected statistics about the fluid andcorresponding wellbore in which the fluid was resident.

Through the steps and decision of routine 260, a fluid can be testedwith a multitude of different gas detectors before the gas makeup of thefluid is outputted with optimized accuracy. However, the various aspectsof routine 260 are not required or limiting as any step and decision canbe added, remove, and changed. For example, a step may be added thatengages the tested fluid with a gas centrifuge to separate gases priorto step 264 and/or step 274.

The ability to provide a mobile gas detection device can allow fluids tobe tested in and in close physical and temporal proximity to theirnative environments so that constituent gases are not contaminated orlost during transport to a testing facility. The construction of themobile gas detection device that allows testing of a fluid with multipledifferent gas detection means individually and concurrently allows alogical algorithm to systematically determine the gas types and amountspresent in the fluid with an optimized accuracy. Furthermore, theability to sense environmental conditions with the mobile gas detectiondevice allows gas detection to adapt to changing environments, such asthe harsh and volatile conditions found in hydrocarbon drillingenvironments.

What is claimed is:
 1. An apparatus comprising a control module having aplurality of different gas detection means housed in a mobile enclosure,the control module configured to activate at least two different gasdetection means to provide amounts and types of gases present in amixture of different gasses.
 2. The apparatus of claim 1, wherein afirst gas detection means comprises one of the following: hot wire,Pellistor, photo ionization, thermal coefficient, infrared, oxygen, andhydrogen sulfide detector.
 3. The apparatus of claim 2, wherein a secondgas detection means comprises one of the following: hot wire, Pellistor,photo ionization, thermal coefficient, infrared, oxygen, and hydrogensulfide detector.
 4. The apparatus of claim 1, wherein at least one gasdetection means comprises a centrifuge.
 5. The apparatus of claim 4,wherein the centrifuge comprises septum disk chamfered along itsperiphery.
 6. The apparatus of claim 1, wherein the control modulecomprises at least one environmental sensor.
 7. The apparatus of claim1, wherein the mobile enclosure comprises the control module and eachgas detection means.
 8. The apparatus of claim 7, wherein the mobileenclosure weighs 100 pounds or less.
 9. A method comprising: providing acontrol module having a plurality of different gas detection meanshoused in a mobile enclosure; and activating at least two different gasdetection means with the control module to provide amounts and types ofgases present in a mixture of different gasses.
 10. The method of claim9, wherein the control module utilizes a logical algorithm resident in alocal memory of the mobile enclosure to differentiate constituent gasesin the fluid.
 11. The method of claim 9, wherein the mixture ofdifferent gasses is entrapped in a drilling mud present in a wellbore.12. The method of claim 9, wherein the amounts and types of gases isoutputted by the control module within five minutes of the fluid exitinga wellbore.
 13. The method of claim 9, wherein at least one gasdetection means uses a centrifuge to separate gas from liquid.
 14. Themethod of claim 13, wherein the control module varies a rotational speedof the centrifuge to maintain laminar flow during extraction and gasseparation induced by the centrifuge.
 15. A method comprising: providinga control module having a plurality of different gas detection meanshoused in a mobile enclosure; activating at least two different gasdetection means with the control module to provide amounts and types ofgases present in a mixture of different gasses; and re-calibrating atleast one gas detection means in response to a threshold accuracy notbeing met.
 16. The method of claim 15, wherein the threshold accuracycomprises the presence of Methane above 1%.
 17. The method of claim 15,wherein the threshold accuracy comprises environmental temperature above50° C.
 18. The method of claim 15, wherein at least one gas detectionmeans is re-calibrated in response to changing environmental conditions.19. The method of claim 15, wherein the control module regulates atemperature of at least one gas detection means.
 20. The method of claim15, wherein a reading from at least one gas detection means is ignoredby the control module in response to the threshold accuracy not beingmet.